CN101717627B - Low-tension foaming agent for improving crude oil extracting rate of high-salinity oil reservoir and preparation method thereof - Google Patents
Low-tension foaming agent for improving crude oil extracting rate of high-salinity oil reservoir and preparation method thereof Download PDFInfo
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- CN101717627B CN101717627B CN 200910230909 CN200910230909A CN101717627B CN 101717627 B CN101717627 B CN 101717627B CN 200910230909 CN200910230909 CN 200910230909 CN 200910230909 A CN200910230909 A CN 200910230909A CN 101717627 B CN101717627 B CN 101717627B
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Abstract
The invention discloses a low-tension foaming agent for improving crude oil extracting rate of a high-salinity oil reservoir and a preparation method thereof, belonging to the field of foaming agents for oil extraction of the oil reservoir. The foaming agent comprises the following components in percentage by weight: 20-70 percent of alkyl-dimethylamine acetolactone, 10-50 percent of lauryl alcohol polyethenoxy ether sulfate sodium salt, 10-50 percent of coconut oleic acid monoethanol amine and 10-60 percent of water. Compared with the prior art, the low-tension foaming agent has the characteristics of strong foaming ability, high foam stability, temperature resistance, high mineralization resistance, high calcium and magnesium ion resistance, good compatibility with stratum water, and the like, and is suitable for the foam flooding of the high-salinity oil reservoir to improve the crude oil extracting rate.
Description
Technical field
The present invention relates to the oil reservoir oil recovery and use foaming agent, specifically a kind of low-tension foaming agent that improves the high salinity reservoir oil recovery factor.
Background technology
At present, most of oil field of Eastern China has got into development late stage---the high moisture and ultra-high water-containing stage.How improving high salt Oilfield developing effect, and how to improve RF behind the polymer flooding, has been the problem that the oil worker presses for solution, needs the three new technology of adopting to improve the RF of high salt maturing field, increases workable reserve.
Foam flooding and foam composite flooding are exactly the new technique that can increase substantially oil recovery factor with wide application prospect of exploitation under present technical background.Foam flooding is to utilize foaming agent to mix the simple foam system displacement of reservoir oil mode that forms with gas; Foam composite flooding is in foam system, to add the flooding method that polymkeric substance such as SEPIGEL 305 strengthens foamy intensity and stability.The key problem of foam flooding and foam composite flooding is developed functional exactly, the foaming agent that stability is strong.
At present, the foaming agent on the market mainly is a sodium lauryl sulphate, the terminal olefin sodium sulfonate; Sodium alkyl benzene sulfonate, products such as alkyl succinic acid sodium are though latherability is stronger; But it is not enough below existing: one of which; Capable relatively poor with the compatibility of local water, especially for high salinity, high contents of calcium and magnesium ionic high salinity reservoir, easily with local water in calcium, mg ion form and precipitate; Two, the foam of formation is very unstable, is very easy to vanish, and when foam and foam compsoite oil drive, needs foam in the stratum, to keep the time as much as possible, therefore, needs foaming properties stable as far as possible; Three, conventional foaming agent is because the IT of itself and crude oil can not arrive ultralow value; Thereby the ability that improves oil displacement efficiency is relatively poor, can not clean up the irreducible oil of oil reservoir, and receive the influence of irreducible oil; Froth stability is poor, is difficult to form stable shutoff profile control ability.Therefore need the development foaming power strong, good stability, good with high salt, high divalent ion local water compatibleness, can reach the heatproof at ultralow interface, ageing-resistant foaming agent with oil reservoir crude oil.
The applicant discloses a kind of foaming agent in publication number is the patent documentation of CN 1651545A; This foaming agent through add multiple stablizer (cocinic acid monoethanolamine, trimethyl-glycine, peroxamine, methylcellulose gum contracts), foam stabilizing additive (sodium-chlor) has improved froth stability, forms strengthening foam.Can improve oil recovery though utilize this foaming agent to carry out foam flooding, it and high salt, high divalent ion local water compatibility are general, only are applicable to that salinity is lower than 50000mg/l, and calcium ions and magnesium ions concentration is lower than the oil reservoir of 10000mg/l.
Summary of the invention
Technical assignment of the present invention is the deficiency to above-mentioned prior art, provide that a kind of oil water interfacial tension reaches ultralow value, foaming power is strong, froth stability good, heatproof, anti-high salinity, the ion of anti-the high contents of calcium and magnesium, with the good low-tension foaming agent of local water compatibleness.
Another technical assignment of the present invention provides the preparation method of above-mentioned foaming agent.
The low-tension foaming agent of raising high salinity reservoir oil recovery factor of the present invention is mixed by host and suds-stabilizing agent.Host is alkyl dimethyl amine second lactone, lauryl alcohol polyethenoxy ether sodium sulfovinate salt; Suds-stabilizing agent is the cocinic acid monoethanolamine.
The consumption of each component is in following weight percentage ranges the time, and this foaming agent all has good displacement of reservoir oil performance:
Be preferably:
The method for preparing above-mentioned low-tension foaming agent may further comprise the steps:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the water and the cocinic acid monoethanolamine that will account for total amount 40%～60% in the time of stirring add reaction kettle;
(2) after the each component dissolving, with the water adding reaction kettle of residual content, stirring and evenly mixing promptly gets the foaming agent finished product in the heated and stirred, question response still.
The method of use of low-tension foaming agent of the present invention is identical with the application method of existing foaming agent in the prior art.Be suitable for oil reservoir: temperature is not higher than 100 ℃, and salinity is lower than 100000mg/l, and calcium ions and magnesium ions concentration is lower than 20000mg/l, and crude oil oil reservoir viscosity is lower than 100mPa.s, oil reservoir permeability range 500 * 10
-3μ m
2～50000 * 10
-3μ m
2
Low-tension foaming agent of the present invention compared with prior art has following outstanding beneficial effect:
(1) alkyl dimethyl amine second lactone and lauryl alcohol polyethenoxy ether sodium sulfovinate salt can improve foam and high salt after composite greatly, high divalent ion local water compatibility is (good with the concentrated water compatibleness of salinity 100000mg/l, calcium ions and magnesium ions concentration 2000mg/l; Foaming properties is unaffected), the tension force that reduces foam and crude oil interface (reaches 10 with isolated island Zhong Er district crude oil IT
-3MN/m);
(2) foaming power is strong, and froth stability is good, is applied to foam compound system shop experiment, and greater than 300ml, the transformation period is greater than 120min for foaming volume (Luo Shi method).
Embodiment
Through concrete preparation embodiment and experimental example low-tension foaming agent of the present invention is described further below.
Preparation embodiment 1:
Raw material:
Alkyl dimethyl amine second lactone 40Kg lauryl alcohol polyethenoxy ether sodium sulfovinate salt 15Kg,
Cocinic acid monoethanolamine 15Kg water 30Kg
Preparation process:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the cocinic acid monoethanolamine of 15Kg water and formula ratio adds reaction kettle in the time of stirring;
(2) after the each component dissolving, remaining 15Kg water is added reaction kettle in the heated and stirred, question response still, stirring and evenly mixing promptly gets water white transparency foaming agent finished product.
Preparation embodiment 2:
Raw material:
Alkyl dimethyl amine second lactone 30Kg lauryl alcohol polyethenoxy ether sodium sulfovinate salt 25Kg,
Cocinic acid monoethanolamine 15Kg water 30Kg
Preparation process:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the cocinic acid monoethanolamine of 15Kg water and formula ratio adds reaction kettle in the time of stirring;
(2) after the each component dissolving, remaining 15Kg water is added reaction kettle in the heated and stirred, question response still, stirring and evenly mixing promptly gets water white transparency foaming agent finished product.
Preparation embodiment 3:
Raw material:
Alkyl dimethyl amine second lactone 50Kg lauryl alcohol polyethenoxy ether sodium sulfovinate salt 15Kg,
Cocinic acid monoethanolamine 15Kg water 20Kg
Preparation process:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the cocinic acid monoethanolamine of 10Kg water and formula ratio adds reaction kettle in the time of stirring;
(2) after the each component dissolving, remaining 10Kg water is added reaction kettle in the heated and stirred, question response still, stirring and evenly mixing promptly gets water white transparency foaming agent finished product.
Preparation embodiment 4:
Raw material:
Alkyl dimethyl amine second lactone 30Kg lauryl alcohol polyethenoxy ether sodium sulfovinate salt 30Kg,
Cocinic acid monoethanolamine 25Kg water 15Kg
Preparation process:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the cocinic acid monoethanolamine of 8Kg water and formula ratio adds reaction kettle in the time of stirring;
(2) after the each component dissolving, remaining 7Kg water is added reaction kettle in the heated and stirred, question response still, stirring and evenly mixing promptly gets water white transparency foaming agent finished product.
Preparation embodiment 5:
Raw material:
Alkyl dimethyl amine second lactone 30Kg lauryl alcohol polyethenoxy ether sodium sulfovinate salt 15Kg,
Cocinic acid monoethanolamine 15Kg water 40Kg
Preparation process:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the cocinic acid monoethanolamine of 20Kg water and formula ratio adds reaction kettle in the time of stirring;
(2) after the each component dissolving, remaining 20Kg water is added reaction kettle in the heated and stirred, question response still, stirring and evenly mixing promptly gets water white transparency foaming agent finished product.
Above-mentioned raw materials is all selected industrial raw material for use.
Experimental example one (is experimental subjects with preparation embodiment 1 gained foaming agent):
Obtain through low-tension foam compound system shop experiment: foaming volume (Luo Shi method) is 360ml, and transformation period 136min reaches 2.2 * 10 with isolated island Zhong Er district crude oil IT
-3MN/m, the experimental water salinity is 6398mg/L, calcium ions and magnesium ions 92mg/L, the water type belongs to NaHCO
3Type, oil density 0.9544g/cm
3, ground viscosity of crude average out to 1132mPas.The drive physical analogue experiment shows, carries out strengthening foam after the water drive and drives raising RF 26%.Polyacrylamide polymers is driven the back strengthening foam and is driven raising RF 16%.
Experimental example two (contrast experiment of conventional foaming agent DP4):
Obtain through shop experiment: foaming volume (Luo Shi method) is 350ml, transformation period 130min, with isolated island Zhong Er district crude oil IT be 0.82mN/m, the experimental water salinity is 6398mg/L, calcium ions and magnesium ions 92mg/L, the water type belongs to NaHCO
3Type, oil density 0.9544g/cm
3, ground viscosity of crude average out to 1132mPas.The drive physical analogue experiment shows, carries out strengthening foam after the water drive and drives raising RF 20%.Polyacrylamide polymers is driven the back strengthening foam and is driven raising RF 11%.
Claims (2)
1. low-tension foaming agent that improves the high salinity reservoir oil recovery factor, this foaming agent is made up of following component by weight percentage:
2. the method for preparing the said low-tension foaming agent of claim 1 is characterized in that this method may further comprise the steps:
(1) alkyl dimethyl amine second lactone and the lauryl alcohol polyethenoxy ether sodium sulfovinate salt with formula ratio joins in the reaction kettle, and the water and the cocinic acid monoethanolamine that will account for total amount 40%～60% in the time of stirring add reaction kettle;
(2) be heated to 70～80 ℃, stir, after the each component dissolving, with the water adding reaction kettle of residual content, stirring and evenly mixing promptly gets the foaming agent finished product in the question response still.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 200910230909 CN101717627B (en) | 2009-11-20 | 2009-11-20 | Low-tension foaming agent for improving crude oil extracting rate of high-salinity oil reservoir and preparation method thereof |
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| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN 200910230909 CN101717627B (en) | 2009-11-20 | 2009-11-20 | Low-tension foaming agent for improving crude oil extracting rate of high-salinity oil reservoir and preparation method thereof |
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| Publication Number | Publication Date |
|---|---|
| CN101717627A CN101717627A (en) | 2010-06-02 |
| CN101717627B true CN101717627B (en) | 2012-12-19 |
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| CN 200910230909 Expired - Fee Related CN101717627B (en) | 2009-11-20 | 2009-11-20 | Low-tension foaming agent for improving crude oil extracting rate of high-salinity oil reservoir and preparation method thereof |
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Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106479470A (en) * | 2015-08-31 | 2017-03-08 | 中国石油化工股份有限公司 | Improve low-tension foaming agent and the flooding method of heterogeneous reservoir oil recovery factor |
Families Citing this family (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102399548B (en) * | 2010-09-15 | 2013-07-31 | 中国石油天然气股份有限公司 | Foaming agent used in composite-foam oil flooding |
| CN106433596A (en) * | 2015-08-05 | 2017-02-22 | 中国石油化工股份有限公司 | Low-tension foaming agent suitable for high-temperature high-salinity oil reservoir |
| CN110343515B (en) * | 2018-04-03 | 2022-04-12 | 中国石油化工股份有限公司 | Salt-loving oil-displacing agent, composition thereof and application thereof in stratum oil displacement |
| CN111879666B (en) * | 2020-07-31 | 2022-07-15 | 西南石油大学 | High-temperature ultrahigh-pressure oil-gas reservoir fluid interfacial tension and contact angle testing device |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4270607A (en) * | 1978-05-01 | 1981-06-02 | Texaco Inc. | Emulsion oil recovery process usable in high temperature, high salinity formations |
| CN1648199A (en) * | 2004-12-09 | 2005-08-03 | 中国石化胜利油田有限公司地质科学研究院 | Foaming agent for improving conventional oil reservoir raw oil recovery rate and its preparing method |
| CN1814692A (en) * | 2005-02-03 | 2006-08-09 | 刘春德 | Carboxyl-betaine and sulfosalt surfactant formula system and use in the third oil-production |
| CN101580705A (en) * | 2009-06-12 | 2009-11-18 | 中国石油大学(华东) | Foaming agent with low gas liquid ratio foam for common heavy oil reservoir and injection method thereof |
-
2009
- 2009-11-20 CN CN 200910230909 patent/CN101717627B/en not_active Expired - Fee Related
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4270607A (en) * | 1978-05-01 | 1981-06-02 | Texaco Inc. | Emulsion oil recovery process usable in high temperature, high salinity formations |
| CN1648199A (en) * | 2004-12-09 | 2005-08-03 | 中国石化胜利油田有限公司地质科学研究院 | Foaming agent for improving conventional oil reservoir raw oil recovery rate and its preparing method |
| CN1814692A (en) * | 2005-02-03 | 2006-08-09 | 刘春德 | Carboxyl-betaine and sulfosalt surfactant formula system and use in the third oil-production |
| CN101580705A (en) * | 2009-06-12 | 2009-11-18 | 中国石油大学(华东) | Foaming agent with low gas liquid ratio foam for common heavy oil reservoir and injection method thereof |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN106479470A (en) * | 2015-08-31 | 2017-03-08 | 中国石油化工股份有限公司 | Improve low-tension foaming agent and the flooding method of heterogeneous reservoir oil recovery factor |
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